Feasibility Study Report

Transcription

1 Generator Interconnection Request Feasibility Study Report For: Click here to enter text. 2x1 Combined Cycle Plant Service Location: Anderson, SC Total Output: 754 MW Commercial Operation Date: 5/1/2016 In-Service Date (if given): 12/31/2015 Prepared By: Orvane Piper Date:2/21/2013

2 Table of Contents 1.0 Introduction Study Assumptions and Methodology Thermal Study Results NRIS Evaluation ERIS Evaluation Fault Duty Study Results Reactive Capability Study Results

3 1.0 Introduction Following are the results of the Generation Feasibility Study for the installation of 754 MW of generating capacity in Anderson County, SC. This site is located near Anderson Tie and has an estimated Commercial Operation Date of 5/1/ Study Assumptions and Methodology The power flow cases used in the study were developed from the Duke internal year 2016 summer peak case. The results of Duke s annual screening were used as a baseline to identify the impact of the new generation. All cases were modified to include 754 MW of new generation at Anderson Tie. To determine the thermal impact on Duke s transmission system, the new generation was modeled with a direct connection to Anderson Tie. The economic generation dispatch was also changed by adding the new generation and forcing it on prior to the dispatch of the remaining Duke Balancing Authority Area units. The study cases were redispatched, solved and saved for use. The NRIS thermal study uses the results of Duke Energy Power Delivery s annual internal screening as a baseline to determine the impact of new generation. The annual internal screening identifies violations of the Duke Energy Power Transmission System Planning Guidelines and this information is used to develop the transmission asset expansion plan. The annual screening provides branch loading for postulated transmission line or transformer contingencies under various generation dispatches. The thermal study results following the inclusion of the new generation were obtained by the same methods, and are therefore comparable to the annual screening. The results are compared to identify significant impacts to the Duke Energy transmission system. The ERIS thermal study utilizes a model that includes the new generation with relevant higher queued projects and associated known upgrades. The new generation economically displaces Duke Balancing Authority Area units. Transmission capacity is available as long as no transmission element is overloaded under N-1 transmission conditions. The thermal evaluation will only consider the base case under N-1 transmission contingencies to determine the availability of transmission capacity. ERIS is service using transmission capacity on an as available basis; adverse generation dispatches that would make the transmission capacity unavailable are not identified. The study will also identify the maximum allowable output without requiring additional Network Upgrades at the time the study is performed. Fault studies are performed by modeling the new generator and previously queued generation ahead of the new generator in the interconnection queue. Any significant changes in fault duty resulting from the new generator s installation are identified. Various faults are placed on the system and their impact versus equipment rating is evaluated. Reactive Capability is evaluated by modeling a facility s generators and step-up transformers (GSUs) at various taps and system voltage conditions. The reactive capability of the facility can be affected by many factors including generator capability limits, excitation limits, and bus voltage limits. The evaluation determines whether sufficient reactive support will be available at the Connection Point. 3

4 3.0 Thermal Study Results 3.1 NRIS Evaluation The following network upgrades were identified as being attributable to the studied generating facility: 2. Install Reactors on Fiber 100 kv 3. Upgrade Fisher 230 kv Lines (Central-Shady Grove Tap) $38.7 M Upgrade Tiger 100 kv Lines (Tiger- Walden Tap) 5. Upgrade Union 100 kv Lines $11.2 M 30 2/0 Cu $4.1 M 18 CUSTOMER TOTAL COST ESTIMATE $61 M 48 4

5 With queued project (355 MW combustion turbine facility in Cleveland County, NC): 2. Upgrade Duncan 100 kv Lines (Inman-Campton Retail) 3. Install Reactors on Fiber 100 kv $2.9 M Upgrade Fisher 230 kv Lines (Central-Shady Grove Tap) $38.7 M Upgrade Tiger 100 kv Lines (Tiger- Lelia Ret) 6. Upgrade Union 100 kv Lines $7.2 M 18 2/0 Cu $4.1 M 18 CUSTOMER TOTAL COST ESTIMATE $59.9 M 48 5

6 With queued project (937 MW combined cycle facility in Cleveland County, NC): 2. Install Reactors on Fiber 100 kv 3. Upgrade Fisher 230 kv Lines (Central-Shady Grove Tap) $38.7 M Upgrade Union 100 kv Lines 2/0 Cu $4.1 M 18 CUSTOMER TOTAL COST ESTIMATE $49.8 M 48 6

7 With queued project (776 MW combined cycle facility in Anderson County, SC): 2. Upgrade Duncan 100 kv Lines (Inman-Campton Retail) 3. Install Reactors on Fiber 100 kv $.4 M Upgrade Fisher 230 kv Lines (Central-Shady Grove Tap) $38.7 M Convert Greenbriar Station to a Switching Station N/A N/A N/A N/A Upgrade Greenbriar 100 kv Lines (Shady Grove-Moonville Retail) $.3 M Upgrade Oakvale 100 kv Lines (Oakvale-Shady Grove) 4.09 N/A Upgrade Piedmont 100 kv Lines (Lee-Shady Grove) $20.8 M Upgrade Tiger 100 kv Lines (Tiger- Walden Tap) 10. Upgrade Union 100 kv Lines $1.1 M /0 Cu N/A 18 CUSTOMER TOTAL COST ESTIMATE $68.3 M 48 For this scenario, the Customer is not responsible for upgrades 5, 7 and This upgrade has been previously identified with queue ID The shown cost reflects a 3 year acceleration of the project rather than the full cost of the upgrade. 2 This upgrade has been previously identified with queue ID The shown cost reflects a 1 year acceleration of the project rather than the full cost of the upgrade. 3 This upgrade has been previously identified with queue ID The shown cost reflects a 2 year acceleration of the project rather than the full cost of the upgrade. 7

8 With queued projects (355 MW combustion turbine facility in Cleveland County, NC) and (776 MW combined cycle facility in Anderson County, SC): 2. Upgrade Duncan 100 kv Lines (Inman-Campton Retail) 3. Install Reactors on Fiber 100 kv 4. Convert Greenbriar Station to a Switching Station $.4 M 4 24 N/A N/A N/A N/A Upgrade Greenbriar 100 kv Lines (Shady Grove-Moonville Retail) N/A Upgrade Oakvale 100 kv Lines (Oakvale-Shady Grove) 4.09 $.3 M Upgrade Piedmont 100 kv Lines (Lee-Shady Grove) $20.8 M Upgrade Tiger 100 kv Lines (Tiger- Walden Tap) 9. Upgrade Union 100 kv Lines N/A 30 2/0 Cu N/A 18 CUSTOMER TOTAL COST ESTIMATE $28.5 M 36 For this scenario, the Customer is not responsible for upgrades 4, 5, 8 and 9. 4 This upgrade has been previously identified with queue ID The shown cost reflects a 3 year acceleration of the project rather than the full cost of the upgrade. 5 This upgrade has been previously identified with queue ID The shown cost reflects a 2 year acceleration of the project rather than the full cost of the upgrade. 8

9 With queued projects (937 MW combined cycle facility in Cleveland County, NC) and (776 MW combined cycle facility in Anderson County, SC): 2. Upgrade Duncan 100 kv Lines (Inman-Campton Retail) 3. Install Reactors on Fiber 100 kv 4. Convert Greenbriar Station to a Switching Station N/A 24 N/A N/A N/A N/A Upgrade Greenbriar 100 kv Lines (Shady Grove-Moonville Retail) N/A Upgrade Oakvale 100 kv Lines (Oakvale-Shady Grove) 4.09 N/A Upgrade Piedmont 100 kv Lines (Lee-Shady Grove) $20.8 M Upgrade Tiger 100 kv Lines (Tiger- Walden Tap) 9. Upgrade Union 100 kv Lines N/A 30 2/0 Cu N/A 18 CUSTOMER TOTAL COST ESTIMATE $27.8 M 36 For this scenario, the Customer is not responsible for upgrades 2, 4-6, 8 and 9. 9

10 3.2 ERIS Evaluation Under the terms of ERIS service, the full output of the plant cannot be delivered at the time the study was performed. If no higher queued projects and their associated known upgrades are built, the maximum output that can be delivered without requiring network upgrades is 470 MW. If only queued project (355 MW combustion turbine facility in Cleveland County, NC) is built along with its associated upgrades, the maximum output that can be delivered without requiring additional network upgrades is 583 MW. In order to deliver the full output of the plant under the terms of ERIS service for the aforementioned scenarios, the following network upgrade was identified as being attributable to the studied generating facility: 1. Upgrade Fisher 230 kv Lines (Central-Shady Grove Tap) $38.7M 48 CUSTOMER TOTAL COST ESTIMATE $38.7M 48 The following scenarios were also studied but did not identify any constraints to delivering the full output of the plant under the terms of ERIS service: With queued project (776 MW combined cycle facility in Anderson County, SC) With queued project (937 MW combined cycle facility in Cleveland County, NC) With queued projects (355 MW combustion turbine facility in Cleveland County, NC) and (776 MW combined cycle facility in Anderson County, SC) With queued projects (937 MW combined cycle facility in Cleveland County, NC) and (776 MW combined cycle facility in Anderson County, SC) 10

11 4.0 Fault Duty Study Results The following breaker replacement is chargeable to the Customer: 1. At Anderson Tie the following 230 kv breaker: Akens Bl Total estimated cost for breaker replacement: $0.3M If QUEUED (776 MW combined cycle facility in Anderson County, SC) is built, the following breaker replacements are chargeable to the Customer: 1. At Anderson Tie the following 230 kv breaker: Akens Bl 2. At Estes Tap the following 100 kv breaker: Stevens Tap Total estimated cost for breaker replacements: $.5M Queued projects (355 MW combustion turbine facility in Cleveland County, NC) and (937 MW combined cycle facility in Cleveland County, NC) do not impact the fault duty in the vicinity of the proposed 754 MW combined cycle facility in Anderson County, SC. 5.0 Reactive Capability Study Results With the proposed generating facility, the level of reactive support supplied by the units has been determined to be acceptable at this time. Evaluation of MVAR flow and voltages in the vicinity of Anderson Tie indicates adequate reactive support exists in the region. The recommended GSU tap setting is kv. Study completed by: Orvane Piper, Duke Energy Reviewed by: Ben Harrison, Duke Energy Director, Transmission Planning 11